08 November 2016

Ahead of the upcoming capacity auctions, this update from the Energy and Finance team at Burges Salmon provides a reminder of the opportunities presented by the market and considers some of the potential issues that prospective investors might encounter.


The Capacity Market, which was introduced as part of the government's Electricity Market Reform, was established to ensure security of electricity supply in light of the increasing diversity of generation technologies in the UK market.

The Capacity Market includes a number of features that make debt investment opportunities attractive. Long-term contracts (in some cases), monthly payment flows, fixed prices indexed annually to CPI and a "creditworthy counterparty" means that funders looking for opportunities should be looking at this market.

The list of Capacity Contracts awarded in the first two auction rounds is publicly available online.

The upcoming auctions are scheduled as follows:

  • 2016 Four year ahead Capacity Auction (T-4) – Tuesday 6 December 2016.
  • 2017 Early Capacity Auction (EA) – Tuesday 31 January 2017.
  • 2017 Transitional Capacity Auction (TA) – Wednesday 22 March 2017.

Capacity Contract

While often referred to as a "Capacity Contract", this term is slightly ambiguous as there is no bilateral contract between the capacity generator and the settlement body responsible for making and receiving payments (the Electricity Settlements Company Limited). Instead a "Capacity Contract" is the combination of three different elements:

  • The obligations under legislation (the Electricity Capacity Regulations 2014).
  • The capacity market rules set out by Ofgem (the Capacity Market Rules 2014).
  • A capacity notice that the generator receives when it is successful in an auction. The capacity notice will set out the price the generator will be paid, the generating capacity and the term (one, three or 15 years).

This arrangement means that instead of delivering energy pursuant to a traditional contract, a generator's obligation to deliver energy is effectively a statutory obligation which applies to the registered holder of a capacity agreement notice, against a statutory right to receive monthly capacity payments.

The primary obligation of the generator is to deliver electricity of a specified quantity during system stress periods as notified by National Grid Electricity Transmission (NGET). NGET will provide four hours' notice after which the generator must either comply with their obligations to generate or face penalties for its failure to do so.

Payment mechanics

All payments are made between the generator and the electricity supplier via the settlement body.

These payments will include:

  • a regular, monthly payment as set out in the capacity notice from the settlement body to the generator
  • any additional payments from the settlement body for over-generation by a generator (applied annually)
  • any penalty fees deducted from the generator for failure to meet their obligations to generate during a stress period (deductions are applied on a monthly basis).

Payments to the generators are funded by electricity suppliers who pay a monthly charge to the settlement body.


In order to ensure the security of supply, on each occasion which there is a failure to generate, the penalty rate is set at 1/24th of the relevant auction clearing price, adjusted for inflation. However, there is a penalty cap of 200% of a plant's monthly income and 100% of its annual income. Penalties will only apply where NGET gave the requisite four hours’ advance notice of a stress period.


There remains scope for generators to extract upside from supplying electricity outside of their Capacity Contract, both via a PPA outside of the Capacity Market and by over-supplying during stress periods.

In any given stress period, any capacity generated over the amount specified by NGET may entitle the generator to an over-generation payment. These payments are funded out of the penalty fees received by the settlement body. The settlement body calculates the rate of payment as the lower of, (a) the penalty rate (as set out above) and, (b) the total penalty revenue, divided by the total volume of over-generation over the last year.

Potential investors might wish to note the potential for equity upside and/or mitigation of revenue risks that this overpayment mechanic creates.

Termination and cure periods

Termination under a Capacity Contract is defined in the Capacity Market Rules 2014 and covers a number of scenarios such as insolvency of the generator, failure to meet key milestones in new build contracts, failure to deliver copies of key agreements to the delivery body and production of electricity by a generator who has submitted an 'Opt-Out Notice'.

Generators are subject to tests throughout the term of their contract which have consequences for the generator if they are not passed. In particular, generators are subject to metering tests which, if not complied with, can result in the termination of their Capacity Contract. However there is no termination right per se for a failure to respond to a call for generation, even on a repeated basis.

The rules also set out certain cure periods in respect of a termination event. Following service of a termination notice, a generator has 20 working days to write to the Secretary of State to apply for an extension of the notice, which can be for up to 60 days in certain circumstances. Within the notice period the generator is then able to set out a cure plan in which they will aim to demonstrate how and when they will comply with the requirements under which the notice has been brought.

The Secretary of State is obliged to consider the cure plans submitted pursuant to a termination notice and has wide ranging powers under the legislation to rescind a termination notice or extend the time period in which a generator must comply with their obligations under the Capacity Contract by up to six months.

Direct Agreements

Due to the fact that there is no bilateral, contractual agreement in place, funders will not be able to protect their position by way of a direct agreement, in contrast to the position under, for example, CfDs. This means funders will need to apply careful scrutiny to the range of termination rights that could apply under the Capacity Market and be satisfied that generators have adequately mitigated the risks. Funders may also ask for some contractual rights to be involved in any appeals process undertaken by the generator further to receipt of a termination notice.

Taking security

There is specific provision under the Capacity Market Rules for generators assigning their rights under the Capacity Market by way of security. The precise nature of that security interest will need to be the subject of legal advice, since the right to receive payment is a statutory right and not a contractual right.

The Capacity Market Rules imply some further conditions of which funders must be aware. Funders can take security over both the generating equipment and the Capacity Contract. However both of those security interests must be registered on the Capacity Market Register, by notifying NGET in the prescribed form.

Additionally, on the enforcement of any security, both the generating equipment and the Capacity Contract must both be transferred together to an "Acceptable Provider" who meets the requirements set out in the rules. This prevents the transfer to any generator who has been in default within the last year, who cannot meet the prescribed credit cover or who does not hold a pre-qualification certificate.

Future developments

The government is currently consulting on changes which would require the settlement body to withhold Capacity Market payments from certain new build generators that are awarded long term Capacity Contracts. 

The generators potentially affected by the change are those that have used (or will use) Enterprise Investment Scheme (EIS) or Venture Capital Trust (VCT) funding in the construction of their Capacity Market Unit. If awarded long term contracts, affected generators would not receive capacity market payments until an amount equal to the total amount of that EIS or VCT money spent on the construction of their new Capacity Market Unit had been recovered.

It is currently proposed that this change, if implemented, will apply to generators awarded long term Capacity Contracts in the upcoming (December 2016) T-4 and early auctions.

While it is not an issue that is specific to the Capacity Market, investors should also be aware of the proposed changes to embedded benefits (the financial benefits accruing to small-scale distribution connected generation as a result of the way in which they are connected to the network). In particular, several ongoing modification proposals to the Connection and Use of System Code (CUSC) seek to end the payment of the TNUoS Demand Residual (commonly known as Triad avoidance benefit). Triad avoidance benefit is principally a benefit enjoyed by non-intermittent embedded generation that can guarantee export during periods of peak demand (triad periods) such as the small scale gas and diesel generators that make up a large proportion of the generation in the Capacity Market.

Ofgem is currently scheduled to make a decision by spring 2017, with any changes being implemented in early 2018. In the meantime, National Grid has written to Ofgem to confirm its view that a holistic review of embedded benefits is required, rather than changes being made through piecemeal CUSC modifications and so this remains an area of uncertainty that merits ongoing review by investors.

Contact us

For further details or to discuss the Capacity Market more broadly, contact James Phillips.

Key contact

James Phillips

James Phillips Partner

  • Head of Energy & Utilities
  • Head of Energy Transition
  • Energy Regulation

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